EP4112876A2 - Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen - Google Patents

Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen Download PDF

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Publication number
EP4112876A2
EP4112876A2 EP22185803.8A EP22185803A EP4112876A2 EP 4112876 A2 EP4112876 A2 EP 4112876A2 EP 22185803 A EP22185803 A EP 22185803A EP 4112876 A2 EP4112876 A2 EP 4112876A2
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European Patent Office
Prior art keywords
tracer
influx
well
model
transient
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EP22185803.8A
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English (en)
French (fr)
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EP4112876A3 (de
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Fridtjof Nyhavn
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Resman AS
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Resman AS
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/10—Locating fluid leaks, intrusions or movements
    • E21B47/11—Locating fluid leaks, intrusions or movements using tracers; using radioactivity
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B27/00—Containers for collecting or depositing substances in boreholes or wells, e.g. bailers, baskets or buckets for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits
    • E21B27/02—Dump bailers, i.e. containers for depositing substances, e.g. cement or acids
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/14—Obtaining from a multiple-zone well
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V9/00—Prospecting or detecting by methods not provided for in groups G01V1/00 - G01V8/00

Definitions

  • the invention is in the field of reservoir monitoring by estimating downhole inflow profiles by exploiting tracer flowback transients in oil and gas wells.
  • the information may be extracted from the onset of tracer transients (a few samples) or from a full transition from one to the next tracer level (several samples over longer time period).
  • the applicant's diffusion tracer release carriers has this feature, that after a possible initial burst of tracers, these will more or less have a long period of approximately constant tracer release.
  • Other tracer sources like packers, seals, cement, etc may not release unique tracers and their position in the well may be uncertain, such as is the case for distributed cement.
  • the constant tracer release rate by diffusion may prove advantageous if the different influx zones have generally equal influx pressures or pressures in equilibrium. Then it is feasible to create the "shots" illustrated in Fig. 1.2 and 1.3 by shutting in the well because no or very little cross-flow between the zones may arise.
  • Downhole tracer concentration shots are made from defined positions in the completion along the wellbore by shutting in or significantly reducing the flow topsides, thus allowing a local build-up of tracer concentration near each tracer carrier. Sampling is conducted at the surface, and concentration change of the tracer and the corresponding time of the their arrival as peaks are registered. In an embodiment this method relies on tracer "shots", i.e. tracers creating small volumes of equally high tracer concentration in the local fluid. In one embodiment this is obtained by utilising the release of the tracer from a polymer arranged in the actual influx zone.
  • the produced oil is sampled at the surface and analyzed for concentration variations and changes in times between the peaks. If there is a high influx of wellbore fluid between two tracer locations, two effects will appear: First, the peak between the two tracer shots will be longer than predicted for an influx that is even all along the completion. Secondly, the tracer shot releasing tracer material being upstream of the high influx zone will pass by the high influx zone on its way to the topsides sampling site, thus its concentration will be diluted compared to the tracer shot material being released downstream.
  • Tracer transients formed by shut-in or otherwise changes in the flow will propagate to the surface as concentration slugs or shots.
  • the tracer transients are driven by the velocity field in the well.
  • the topside arrivals of the onset of the different tracers, or the full transient of the different tracers, can be used to estimate the downhole velocity field. From the velocity field the inflow profile may be calculated.
  • Background art tracer systems other than the applicant's system have shorter active release periods and have erosion- or dissolution-based release of the tracer chemicals. This requires a fundamentally different approach during interpretation than for the present invention since the release of such background art systems is more directly linked to the production rates. Longevity in wells may in such cases generally not be predicted since the tracer will be used up rather according to cumulative production volume than being released at a constant rate with time.
  • array of mechanical chambers that is placed along the production zone and will give a tracer shot per location at given synchronized points in time.
  • the tracer shots that are created will travel to the surface with the produced fluids.
  • Flow profiles may be estimated from the measurements of concentration of the different tracer materials conducted at the surface or elsewhere downstream.
  • the invention is a method of exploiting tracer transients from producing wells. This may involve the whole or parts of the value chain from downhole tracer release, sampling and analysis and finally extracting the necessary information from tracer transients.
  • the invention defined in claim 1 is a method of estimating an influx profile (q i ) for at least one of the well fluids (oil, gas, or water) to a producing petroleum well (1) with two or more influx zones or influx locations (3, 31, 32, 33) to a production flow (F), comprising the following steps:
  • the following steps may be used for establishing a steady-state well flow tracer concentration level by sampling and analysing before the shut-in:
  • the method may also be defined as a system for estimating an influx profile (q i ) for at least one of the well fluids (oil, gas, or water) to a producing petroleum well (1) with two or more influx zones or influx locations (3, 31, 32, 33) to a production flow (F), comprising:
  • Fig. 1 shows a series of diagrams to visualize how the tracer concentrations change as they are transported across the reservoir interval. The downstream piping system and topside equipment is not illustrated.
  • FIG. 1 nine frames are shown, Fig. 1-1 to 1-9 illustrating the technique.
  • Each frame is a time step and describe how the tracer shots move after being built up as a result of a topside shut-in of the well or a significant reduction of the well flow.
  • the diagrams represents a horizontal well, here shown with four tracers of generally constant release per time unit, installed at four positions labelled A, B, C, D. For simplicity in this example the distances between each subsequent tracer position along the wellbore are equal. In a real case there may be many more different tracers installed in a well at a corresponding number of locations.
  • the tracer matrix devices are exposed to the well fluids either from the outside of the completion or inside depending on the carrier system.
  • the tracers are released to the fluids at an even rate with time.
  • the tracers are concentrated up locally as illustrated in Fig. 1-2 .
  • the fluids immediately surrounding the tracer develop a high concentration of the tracer.
  • Such volumes are referred to as a "tracer shot” and typically start off as equal volumes.
  • each vertical arrow in this example represent a given flow for example 1000 bopd (barrels of oil per day).
  • Fig. 2 is an idealised illustration of concentration of identified tracers sampled topside, with time or cumulative production volume (since the release of the flow) as the abscissa.
  • Fig. 3 is an illustration of an approach for matching the unknown downhole influx rates in the downhole production zones with the modelled influx rates.
  • the model influx rates are adjusted until the calculated concentrations of model tracers compare well with the measured concentrations of identified tracers.
  • Fig. 4 shows different configurations for the downhole completions and how the tracer systems are placed into these, please see the red rods.
  • Fig. 5a is a simplified section through a petroleum well. Influx volumes of fluids enters from the reservoir rocks to end up in a production flow in a central production pipe in the well provided with two or more separate influx locations. In this situation the influx zones may not be precisely known and it is not taken for granted that the tracers are placed where the influx exactly occurs.
  • Fig. 5b is a simplified section through a petroleum well wherein packers are arranged for mutually isolating the influx zones. In this situation the tracers are also placed each in its separate influx zone. There may be many more influx zones and tracer carriers than what is illustrated in Fig. 5a and b.
  • Fig. 6 shows an influx control device sub arranged for being arranged in-line with the production tubing and is provided with a partially cut-away screen towards the surrounding rocks (not shown) in the borehole in an influx zone, and with polymer rods with tracer materials arranged in the annular space under the screen, and with exit holes for fluid arranged at the downstream end of the sub.
  • Fig. 8 for a section through such an arrangement. No leaked-out tracers are indicated.
  • Fig. 7 illustrates the same influx control device sub as in Fig.
  • Fig. 8 comprises illustrations of a situation according to the invention wherein the tracer shot is built over time from the tracer leak-out from polymers into still shut-in fluids. The flow-back of the shot to surface is then done during production ramp-up. In this example, the shut in of the flow is a transient in time with a resulting build-up of the shot.
  • Fig. 8a illustrates one insulated influx zone insulated by a lower (right) and an upper (left) packer defining a zone of influx of petroleum fluids (and / or water) entering the annulus about the production tubing, the fluids passing a polymer carried tracer, and the fluids with more or less tracer material leaving the annulus space through apertures in the central production tube to the production flow which passes towards the topside.
  • Fig. 8a illustrates a situation wherein the topsides flow is flowing, and wherein the tracer is released more or less at a constant rate over long time, e.g. tracers from a polymer rod arranged in the annular space outside the central production tube. The fluid carries tracer with it at a generally even rate with the production flow.
  • Fig. 8b illustrates the result of a shut-in downstream (topside) in order to build a concentration in the annulus space, called to build a "shot".
  • topside shut-in downstream
  • a tracer shot of short spatial extension is created.
  • the dispersion of the tracer material will be a function of turbulence and flow geometry in the annulus space, and if the flow topsides is halted, one would expect the dispersion within the void to be very little.
  • Fig. 8c illustrates that the tracer concentrated fluid (the "shot") is flushed out with resumption of the production by opening the topside valve, and the built-up shot will be flushed out as a longer pulse than what would have been obtained if the tracer was built up directly to the still-standing production flow.
  • the concentration of the tracer as sampled and measured topside will be similar to one of the curves of Fig. 2 .
  • Fig. 9 shows ideal curves of tracer shot release into the base pipe from the annulus void of Fig. 8c into the central production pipe (base pipe) as a function of time or cumulative flow, in the situation of shut-in with long term release of tracer, and subsequent release. Please notice that both curves cannot approach nil concentration as the doses are continually released. The higher rate will flush out fastest and die out faster, while the lower influx rate will wash out at a lower rate, but both may be at a detectable level for very long time.
  • Fig. 10 relates to a setup with accumulated tracer shots being flushed into the central base pipe, or already built up in the central base pipe, as also explained in Fig. 1 .
  • Fig. 10 shows curves of tracer concentrations as function of cumulative production volume topside.
  • zone 1 and "zone 1 & 5" (which may produce into the same main well) or two wells on the same tie-back, leading to the same topsides sampling site.
  • the vertical coloured lines are the positions of tracers in insulated influx zones to the two branches.
  • the different coloured lines in the curves indicate measured concentrations (interpolated).
  • Fig. 11 shows the same measured curves and well models as for Fig. 10 above.
  • a general scheme of comparison between the Real World and the model world as shown in Fig. 3 may be used. The difference is that here the influx model of "zone 1" and “zone 1 & 5" are heavily corrected to indicate influx rates downhole "zone 1" of 18%, only 1%, and as high as 43% contributions to the combined total flow topside, and for zone 1 & 5 contributions of 9% at the heel, 10%, and 18% at the toe.
  • zone 1 & 5 contributions of 9% at the heel, 10%, and 18% at the toe.
  • the middle production zone of "zone 1" contributes insignificantly and may be shut down or considered as a candidate for an overhaul.
  • the predicted peak arrivals coincide with the actual peaks.
  • Fig. 3 provides an overview description of how a tracer transient interpretation system may be designed.
  • the main objective is to produce interpretation reports that tells the well operator about the downhole inflow profiles. These may then plug into the customer's decision processes.
  • Crucial are the different models and the model should be tuneable so that history matching deviations can be reduced.
  • the invention is a method of estimating an influx profile (q i ) for at least one of the well fluids (oil, gas, or water) to a producing petroleum well (1) with two or more influx zones or influx locations (3, 31, 32, 33) to a production flow (F).
  • the method comprises the following steps:
  • the following steps may be used for establishing a steady-state well flow tracer concentration level by sampling and analysing before the shut-in:
  • the flow transient may be induced e.g. by making a step change, e.g. increase or reduction, in the overall production rate of the well, shutting down the well for a time and re-opening it.
  • a series of step changes may be introduced.
  • Other transients than step changes may be imagined, but the transient must have sufficient amplitude and temporal significance in order to be detected downstream through the often long material piping system.
  • shut-in time is sufficiently long so as for the transient to be detectable downstream.
  • a better alternative is to assume steady-state flow is reached after shut-in and resumption of flow after a given time, usually indicated in the curves when the concentrations of tracers have approached their base levels again.
  • the transient in the production rate (q) may be induced by shutting down said production flow (F), such as by shutting down topside at a first instant.
  • the shutdown will result in a local accumulation of the tracer material (4m, 41m, 42m, 43m) near the tracer sources.
  • the production rate (q) is increased by opening the production flow at a desired known instant. This may be called creating an artificial "tracer shot", where the tracer sources themselves need not be manipulated.
  • local chemically traceable pollutants such as decaying gaskets or cements may be utilized, but a method using known tracers with known properties and arranged at known locations are preferred.
  • a transient in the production rate (q) is induced locally by shutting down one or more of said local influx rates (q21, q22, q23%), such as by shutting down local valves, at a first instant, for local accumulation of at least some of the tracer's tracer material (4m, 41m, 42m, 43m) near the tracer sources, and for subsequently increasing the production rate (q) by increasing those one or more of said influx rates (q21, q22, q23%), such as opening the local valves to full aperture (or their ordinary operating aperture, which may be less than full for some valves), at a desired known instant.
  • the analysis of the samples (c1, c2, c3, ...c N ) for the concentrations (4c, 41c, 42c, 43c, ...) and type of tracer materials (4m, 41m, 42m, 43m) from the possible sources (4, 41, 42, 43) is conducted generally after the sampling is done at one or more of said sampling times. This is particularly valid if the concentrations are very low and the analysis is time-consuming and requires high accuracy in a lab.
  • the analysis of the concentrations (4c, 41c, 42c, 43c, ...) of tracer materials (4m, 41m, 42m, 43m) in the samples (c1, c2, c3, ...c N ) may be conducted on site, generally simultaneously, immediately during or after the sampling conducted at the one or more of said sampling times.
  • This embodiment of the method may be relevant if the tracer concentration and thus the detectability is sufficiently high so as to enable immediate, rapid analysis, such as by using a chemical sensor in the production flow, or extracting samples that are analyzed automatically there and then at the topside location.
  • a sensor may provide concentration measurements more or less continuously.
  • Such a sensor may further provide a measurement signal online.
  • one or more of the tracer sources (4, 41, 42, 43) is arranged in a separate corresponding one or more delay chambers (7), please see Fig. 6 and Fig. 7 , the delay chamber having one or more apertures (71) to the fluid flow, the delay chamber (7) arranged for ventilating out fluid with leaked tracer material at a time constant which is significantly longer than the diffusion rate from the tracer source (4, 41, 42, 43) to the liquid.
  • Such a delay chamber (7) may be constituted by an ordinary component of the well, such as a completion pipe whereupon the one or more tracer source (4, 41, 42, 43) is arranged in the annular space formed between said completion pipe and the borehole wall, please see Figs. 6, 7 , and 8 .
  • the transient in production flow utilized in an embodiment of the invention does not necessarily be induced solely for the purpose of the present method, but may occur in the system anyway.
  • the transient used in the invention may be a naturally or technically occurring transient in the production rate, such as a temporary shutdown of the production for minutes or hours, the closing and / or opening of valves from tracer marked portions of the production pipe, which may be utilised as the actual transient in the production rate.
  • the influx profile (q i ) comprises two or more influx rates (q21, q22, q23%) in two or more corresponding influx zones or influx locations (31, 32, 33, ).
  • the calculation of the influx profile (q i ), an abstract model well (1') corresponding to the actual production well (1) is established, including a model transport path (P') corresponding to said well's (1) transport path (P) downstream of, that is afte r said influx profile (q i ), nearer to the wellhead.
  • Fig. 1 a series of diagrams are provided to help visualize how the tracer concentrations change as they are transported across the reservoir interval.
  • FIG. 1-1 to 1-9 illustrate the technique.
  • Each frame is a time step and describe how the tracer shots move after being built up as a result of either a shut-in of the well flow or a change in well flow.
  • the diagram represents a horizontal well with four tracers of generally constant release per time unit, installed at positions labelled A, B, C, D. For simplicity in this example the distances between each subsequent tracer position along the wellbore are equal.
  • the tracer matrix devices are exposed to the well fluids either from the outside of the completion or inside depending on the carrier system. When they come in contact with oil (or water if they are a water tracer system) the tracer chemicals are emitted from the matrix at a fairly constant rate. If there is no flow as illustrated in Fig. 1-2 , then the fluids immediately surrounding the tracer develop a high concentration of the tracer. Such volumes are referred to as a "tracer shot" and typically start off as equal volumes.
  • each vertical arrow in this example represent a given flow for example 1000 bopd (barrels of oil per day).

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EP22185803.8A 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen Pending EP4112876A3 (de)

Applications Claiming Priority (5)

Application Number Priority Date Filing Date Title
US40814310P 2010-10-29 2010-10-29
NO20101521A NO334117B1 (no) 2010-10-29 2010-10-29 En fremgangsmåte for estimering av et innstrømningsprofil for i det minste en av brønnfluidene olje, gass eller vann til en produserende petroleumsbrønn
EP15191546.9A EP3032028B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP11785802.7A EP2633152B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
PCT/NO2011/000306 WO2012057634A1 (en) 2010-10-29 2011-10-31 Method for using tracer flowback for estimating influx volumes of fluids from different influx zones

Related Parent Applications (2)

Application Number Title Priority Date Filing Date
EP15191546.9A Division EP3032028B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP11785802.7A Division EP2633152B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen

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EP4112876A2 true EP4112876A2 (de) 2023-01-04
EP4112876A3 EP4112876A3 (de) 2023-02-22

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EP15191546.9A Active EP3032028B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP22185803.8A Pending EP4112876A3 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP15191547.7A Active EP3075949B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP11785802.7A Active EP2633152B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen

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EP15191547.7A Active EP3075949B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen
EP11785802.7A Active EP2633152B1 (de) 2010-10-29 2011-10-31 Verfahren zur verwendung von tracer-rückfluss zur schätzung der einstromvolumina aus verschiedenen einstromzonen

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US (6) US8949029B2 (de)
EP (4) EP3032028B1 (de)
AU (1) AU2011321097B2 (de)
BR (1) BR112013010529B1 (de)
CA (1) CA2852632C (de)
MX (1) MX2013004815A (de)
NO (1) NO334117B1 (de)
WO (1) WO2012057634A1 (de)

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US20200270986A1 (en) 2020-08-27
US20210199003A1 (en) 2021-07-01
US10871067B2 (en) 2020-12-22
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US10253619B2 (en) 2019-04-09
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AU2011321097B2 (en) 2017-03-16
EP3075949B1 (de) 2022-07-20
EP2633152B1 (de) 2016-07-06
CA2852632C (en) 2019-12-03
EP3075949A2 (de) 2016-10-05
BR112013010529A2 (pt) 2017-10-10
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US20130245948A1 (en) 2013-09-19
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US20130268198A1 (en) 2013-10-10
US10669839B2 (en) 2020-06-02
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CA2852632A1 (en) 2012-05-03
US11674382B2 (en) 2023-06-13
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US20200270985A1 (en) 2020-08-27
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